Photovoltaic system installation

ABSTRACT

The present invention is directed to a photovoltaic installation process. A process may include determining a method of interconnection to couple a photovoltaic system to an electrical system of a structure. The process may further include determining, via an electronic device, an ideal usage offset ratio for the photovoltaic system based on a known utility rate associated with the structure. Moreover, the process may include estimating a number of modules required to meet the determined ideal usage offset ratio. In addition, the process may include generating, via the electronic device, installation information including required installation materials, estimated costs, point-load, and electrical information for the photovoltaic system.

CROSS-REFERENCE TO RELATED APPLICATION

A claim for the benefit of priority to the Apr. 10, 2014 filing date ofU.S. Provisional Patent Application No. 61/977,760, titled PHOTOVOLTAICSYSTEM INSTALLATION (“the '760 Provisional Application”), is hereby madepursuant to 35 U.S.C. § 119(e). The entire disclosure of the '760Provisional Application is, hereby incorporated herein.

TECHNICAL FIELD

This disclosure relates generally to photovoltaic systems and, morespecifically, to installation of photovoltaic systems.

BACKGROUND OF RELATED ART

Solar panels, which may include a set of solar photovoltaic modules, uselight energy (photons) from the sun to generate electricity through thephotovoltaic effect. A photovoltaic system including a plurality ofsolar panels and various other electrical components may be used togenerate and supply electricity in commercial and residentialapplications.

The addition of solar panels to new and existing structures is becomingincreasingly popular due to growing public awareness about energyindependence, the desire to curb rising energy costs, and the increasedaffordability of solar panels.

BRIEF SUMMARY OF THE INVENTION

In one specific embodiment, a photovoltaic installation process mayinclude determining a method of interconnection to couple a photovoltaicsystem to an electrical system of a structure. The process may furtherinclude determining, via an electronic device, an ideal usage offsetratio for the photovoltaic system based on a known utility rateassociated with the structure. Moreover, the process may includeestimating a number of modules required to meet the determined idealusage offset ratio. In addition, the process may include generating, viathe electronic device, installation information with a design toolincluding required installation materials, estimated costs, point-load,and electrical information for the photovoltaic system.

In another specific embodiment, a system includes an electronic deviceincluding a processor. The system also includes a computer-readablemedium coupled to the processor. Further, the system may include anapplication program stored in the computer-readable medium. Theapplication program, when executed by the processor, is configured todetermine an ideal usage offset ratio for the photovoltaic system basedon one or more parameters associated with a structure having a knownlocation. The application program may also be configured to estimate anumber of modules required to meet the determined ideal usage offsetratio. In addition, the application program may be configured togenerate installation information for the photovoltaic system based atleast partially on location-specific information and the estimatednumber of modules.

Yet other embodiments of the present disclosure comprisecomputer-readable media storage storing instructions that when executedby a processor cause the processor to perform instructions in accordancewith one or more embodiments described herein.

Other aspects, as well as features and advantages of various aspects, ofthe present invention will become apparent to those of ordinary skill inthe art through consideration of the ensuing description, theaccompanying drawings and the appended claims.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 illustrates a system including an electronic device, according toan embodiment of the present disclosure;

FIG. 2 illustrates a process, in accordance with an embodiment of thepresent disclosure;

FIG. 3 is a screenshot depicting example documents of a site survey;

FIG. 4 is a screenshot depicting example photographs used in determininga method of interconnection for a photovoltaic system;

FIG. 5 is a screenshot illustrating an energy statement and a softwaredesign tool;

FIG. 6 is a screenshot illustrating a design folder and a softwaredesign tool;

FIG. 7 is a screenshot depicting an aerial photograph of a propertyincluding a structure;

FIG. 8 is a screenshot depicting another aerial photograph of theproperty shown in FIG. 7;

FIG. 9 is a screenshot depicting example roof plans for a photovoltaicsystem;

FIG. 10 is a screenshot illustrating example roof plans with requiredoffsets;

FIG. 11 is a screenshot depicting example roof plans including aplurality of modules;

FIG. 12 is a screenshot illustrating a sky photograph;

FIG. 13 is a screenshot illustrating a roof plan generated in a softwaretool;

FIG. 14 is a screenshot depicting example roof plans including aplurality of modules;

FIG. 15 is a screenshot depicting example roof plans including aplurality of modules, trunk cable, and hatching;

FIG. 16 is a screenshot depicting example roof plans including aplurality of modules, trunk cable, hatching, and a conduit;

FIG. 17 is a screenshot illustrating example shading reports andproduction estimates for a photovoltaic system;

FIG. 18 is a screenshot illustrating an example software tool;

FIG. 19 is a screenshot depicting an example photograph for generating asite plan for a photovoltaic system;

FIG. 20 is a screenshot depicting a site plan including a plurality ofmodules;

FIG. 21 is a screenshot illustrating a conduit and a plurality ofmodules on a site;

FIG. 22 is a screenshot illustrating a site plan and a drawingproperties window;

FIG. 23 is a screenshot depicting notes on a site plan;

FIG. 24 is a screenshot depicting notes on a roof plan;

FIG. 25 is a screenshot illustrating a one-line diagram for aphotovoltaic system in a computer-aided design program;

FIG. 26 is a screenshot depicting computer-aided drawings beingpublished;

FIG. 27 is another screenshot illustrating computer-aided drawings beingpublished;

FIG. 28 is a screenshot depicting a software design tool;

FIG. 29 is another screenshot depicting the software design toolillustrated in FIG. 28;

FIG. 30 is a screenshot depicting engineering documents being mergedinto an engineering packet for a photovoltaic system;

FIG. 31 is a screenshot illustrating various documents being merged intoan installer packet for a photovoltaic system;

FIG. 32 is a screenshot including a photograph including a module;

FIG. 33 is a screenshot depicting a customer packet for a photovoltaicsystem;

FIG. 34 is a screenshot depicting a customer design folder for aphotovoltaic system;

FIG. 35 is a screenshot illustrating a management system forphotovoltaic systems;

FIG. 36 is a screenshot depicting files from a customer design folder;

FIG. 37 is another screenshot illustrating a management system;

FIG. 38 is yet another screenshot of a management system; and

FIG. 39 is a flowchart of a method, according to an embodiment of thepresent disclosure.

DETAILED DESCRIPTION

Referring in general to the accompanying drawings, various embodimentsof the present invention are illustrated to show the structure andmethods for installing a system, such as a photovoltaic system. Commonelements of the illustrated embodiments are designated with likenumerals. It should be understood that the figures presented are notmeant to be illustrative of actual views of any particular portion ofthe actual device structure, but are merely schematic representationswhich are employed to more clearly and fully depict embodiments of theinvention.

The following provides a more detailed description of the presentinvention and various representative embodiments thereof. In thisdescription, functions may be shown in block diagram form in order notto obscure the present invention in unnecessary detail. Additionally,block definitions and partitioning of logic between various blocks isexemplary of a specific implementation. It will be readily apparent toone of ordinary skill in the art that the present invention may bepracticed by numerous other partitioning solutions. For the most part,details concerning timing considerations and the like have been omittedwhere such details are not necessary to obtain a complete understandingof the present invention and are within the abilities of persons ofordinary skill in the relevant art.

FIG. 1 is a block diagram illustrating an embodiment of system 50including an electronic device 51 comprising a processor 52 and memory54. Processor 52 may comprise any known and suitable processor. Memory54 may include an application program 56 and data 58, which may comprisestored data. Application program 56 may include instructions that, whenread and executed by processor 52, may cause processor 52 to performsteps necessary to implement and/or use embodiments of the presentdisclosure. Application program 56 and/or operating instructions mayalso be tangibly embodied in memory 54, thereby making a computerprogram product or article of manufacture according to an embodiment ofthe present disclosure. As such, the term “application program” as usedherein is intended to encompass a computer program accessible from anycomputer readable device or media. Further, application program 56 maybe configured to access and manipulate data 58 stored in memory 54 ofelectronic device 51. In addition, memory 54 may be configured forstoring any data (i.e., information) related to a photovoltaic systemand/or a process of installing a photovoltaic system.

FIG. 2 is a flowchart illustrating a process 100, in accordance with anembodiment of the present disclosure. Process 100 includes various actsthat may be performed during installation of a photovoltaic system. Itis noted that although the acts of process 100 are presented in aspecific order, the present disclosure does require that the acts beperformed in the disclosed order, or any other sequential order. Rather,the acts described herein may be performed in any suitable order, aswill be appreciated by a person having ordinary skill in the art. It isfurther noted that process 100 does not require each disclosed act forperforming a photovoltaic installation process.

With reference to FIGS. 2-38, process 100 will now be described. Process100 may include completing a site survey (depicted by reference numeral102), which may include gathering various information (“site surveyinformation”) about a job site (e.g., a residential or commercialstructure). For example only, site survey information may include, butis not limited to, customer information, electrical information, atticinformation (except in the case of finished attics or exposed beamceilings), and roof illustrations (e.g., one illustration for each roofsection surveyed) including roof measurements (e.g., a run measurement),roof obstruction locations, and sky picture locations (i.e., photos ofthe sky at different locations on the roof) (e.g., 4 or more per roofsection). Moreover, for each sky picture location marked on the sitesurvey, a full resolution image (e.g., a “.jpg” image thumbnail) and“.sky” file may be obtained. Site survey information may further includeone or more photographs. For example, the site survey information mayinclude one or more photographs of the structure (e.g., full frontalphotographs of the structure), one or more editable (e.g.,“Photoshop-able”) photographs, one or more photographs of a power meter(e.g., from 25 feet away, a close-up (i.e., close enough to read meternumber)), one or more photographs of an electrical utility bill (i.e.,with name, account number and/or electrical usage graph), and/or one ormore photographs of an additional utility bill, if more than one meterexists. In addition, the site survey information may include one or morephotographs of an electrical panel and/or subpanel(s) (e.g., aphotograph taken from 15 feet away, a close-up photograph of entire busbar so all breaker ratings can be read, a photograph of a panel ratingsticker, and a photograph of a main disconnect). Furthermore, the sitesurvey information may include one or more roof-top photographs (e.g., 1or more per roof section), one or more general attic photographs, one ormore photographs of a rafter illustrating rafter size, rafter spacing,rafter lumber grade stamp, or a combination thereof. Moreover, if thestructure (e.g., a house) includes a finished attic, one or morephotographs of a finished drywall ceiling may be included in the sitesurvey information.

Further, site survey information may include a customer utility bill andusage information (e.g., customer name, electrical service address,customer account number, electrical meter number (i.e., that matches themeter number in a site survey photograph), schedule rate, discountscustomer has qualified for, tiered usage graph, and electricity usagehistory (e.g., four or more months of history). It is noted that thetiered usage information (e.g., a tiered usage graph) may only berequired for certain electric companies (e.g., Southern CaliforniaElectric and San Diego Gas and Electric). The site survey informationmay be stored in one or more electronic files and uploaded to a centralaccessible database (e.g., Dropbox). FIG. 3 is a screenshot 200depicting various example documents 202 included in a site survey.

In addition, process 100 may further include verifying that a sitesurvey includes all necessary files and information to at least begin aphotovoltaic installation process (depicted by reference numeral 104).According to one embodiment, a technician (e.g., a pre-designtechnician) may verify that the site survey includes all necessary filesand information.

Process 100 may further include determining a method of interconnectionto an electrical panel in accordance with local electrical codes(depicted by numeral 106). According to one embodiment, a technician(e.g., a pre-design technician) may determine a method ofinterconnection to the electrical panel. The method of interconnectionmay be at least partially based on one or more electrical photographsfrom the site survey. FIG. 4 is a screenshot 210 including examplephotographs 212A-212D that may be used in determining a method ofinterconnection.

Interconnection methods may include utilizing an “interior load breaker”connection wherein a main electrical panel includes a main disconnectand a main electrical panel bus bar has unused space or a breaker thatcan be consolidated to make room for the solar breaker. Anotherinterconnection may include an “existing subpanel” connection wherein amain electrical panel includes a main disconnect, a main bus bar doesnot include space for a solar breaker, and an electrical subpanel hasunused space or a breaker that can be consolidated to make room for thesolar breaker. Yet another interconnection includes a “new subpanel.”This connection may be used when a main electrical panel includes a maindisconnect, a main bus bar does not include space for a solar breaker, anew electrical subpanel is installed according to code specifications,one breaker is moved from the main electrical panel to the newelectrical subpanel to make room for a new subpanel disconnect, and thesolar breaker is placed on a new subpanel bus bar.

A “supply tap,” which is another interconnection, includes an electricaltap attached to supply wires inside a main disconnect box. Theelectrical tap may require at least 6 inches of supply wire. It is notedthat that the supply tap connection may only be an option in certaingeographical regions (e.g., East Coast of the United States). Anotherexample, is a “supply breaker” connection, which is a connection whereinan electrical meter connects directly to a small bus bar, which includesbreakers to a main electrical panel and other things. Further, in thisconnection, a small bus bar has used space or a breaker that can beconsolidated to make room for a solar breaker, and the supply breakerincludes six or fewer disconnects on the small bus bar. In addition, aninterconnection may include a “re-directed main” connection. In thisconnection, an electrical meter connects directly to a supply side busbar, the supply side bus bar includes breakers to a main electricalpanel and other components. Moreover, in this connection, the supplyside bus bar does not include space for a solar breaker, the maindisconnect is moved from the supply side bus bar to a new subpanel, anda solar breaker is placed on the new subpanel bus bar.

Regardless of a type of interconnection, if a main disconnect is locatedin the center of the bus bar and has an equivalent rating to the busbar, a 100% multiplier, instead of a standard 120% multiplier, may berequired to determine available amps. In these cases, interconnectionmay not be available.

Process 100 may further include determining an ideal usageoffset-to-savings ratio and estimating the number of modules necessaryto meet that offset (depicted by numeral 108). According to oneembodiment, a technician (e.g., a pre-design technician) may determinean ideal usage offset-to-savings ratio and estimate the number ofmodules necessary to meet that offset. The ideal usage offset-to-savingsratio may be substantially equal to the amount of power generated by thephotovoltaic system relative to the amount of power used by theresidence. For example, if a structure (e.g., a house) is using 100kilowatt hours per month and the photovoltaic system is generating 80kilowatt hours per month, the offset-to-savings ratio is equal to 80%.By way of example, some general rules of determining usage offsetpercentages may include a default offset of 80%, a usage offset of 100%in Hawaii, and a 5% minimum required annual savings. It is noted thatthe offset should be maximized and, according to one non-limitingembodiment, a minimum of six solar modules may be used. It is furthernoted that determining usage offset percentages may incorporate anannual savings calculator, which incorporates one or more parameters(e.g., different utility rates and utility discounts). Further, thenumber of modules estimated may be calculated based on a customer'sannual usage divided by a module rating. FIG. 5 illustrates a screenshot220 of an energy statement 222 and a software design tool 224.

As will be appreciated by a person having ordinary skill in the art, ahandheld device (e.g., a Solmetric SunEye device developed by SolmetricCorp. of Sabastopol, Calif.) may include an integrated electroniccompass, tilt sensing technology, GPS, and camera. The handheld deviceallows for photographs of the sky to be taken at different locations ona roof of a structure. Further, the handheld device may include built-infeatures to integrate roof tilt, azimuth, location, and shadinginformation into the photographs. The photographs may estimate theshading; however, these estimates, which may be shown as coloring on aphotograph, often need adjustment (e.g., by a design technician) toensure the optimal accuracy. The combination of all photographs andinformation on a given roof is compiled into a “session” that isaccessible and editable through software (e.g., PV Designer softwaredeveloped by Solmetric Corp.).

Process 100 further includes setting up a customer design folder (i.e.,via moving over a site survey form, one or more photographs, and asession (e.g., a Solmetric SunEye session developed by Solmetric Corp)from a site survey folder and generating a design tool (depicted bynumeral 110). According to one embodiment, a technician (e.g., apre-design technician) may set up a customer design folder and generatea design tool for a design technician. A design tool, which may includeand/or utilize at least a portion of application program 56, data 58,and processor 52 (see FIG. 1), may contain information specific to thecustomer's account and location-specific information on pre-design,design, and computer-aided design (CAD) requirements (e.g., roof offsetrequirements, interconnection options, additional steps, etc.). Thedesign tool may also contain formulas and calculators for engineering,usage, and verification calculations (e.g., point-load, estimated numberof modules, customer savings, ideal usage offset-to-savings ratios,etc.). The design tool may include any data that may be valuable to adesigner. As one example, the design tool may include data for variouscodes and/requirements for various cities, states, and/or home ownersassociations (HOAs). Further, National Electrical Code (NEC) andCalifornia Electrical Code (CEC) calculations may be included within thedesign tool. According to one embodiment, a number of modules may beprovided to the design tool, which may then calculate variousparameters, such as required wire gauges, breaker sizes, and voltagedrops.

The design tool may be configured to generate one or more documents foruse in permitting and installation. For example, the design tool maygenerate a data document, which includes information on system materialsand costs, and an engineering document, which includes point-load andelectrical information.

Once CAD requirements are complete, the customer design folder mayinclude a sub-folder including the session files (e.g., Solmetric SunEyesession files), photographs taken by a site surveyor (e.g., within asub-folder), a site survey form (e.g., within a sub-folder), a CADdrawing file specific to a customer's account, a design tool specific toa customer's account, an estimated production report (e.g., an estimatedproduction report generated by Solmetric Corp.), one or more PDF files,or any combination thereof. The one or more PDF files may includepublished CAD files, a customer packet, an engineering packet, aninstaller packet, engineering information, bill of materials, a designtool printout, or any combination thereof. Further, the customer designfolder may include a modified (e.g., “Photoshopped”) image of one ormore modules on a structure (i.e., when a good image is available), anyprevious design options (e.g., if a redesign has been performed),relevant notes or correspondence (e.g., when exceptions are made or whenspecial cases arise), or any combination thereof. FIG. 6 is a screenshot230 depicting an example customer design folder 232 and a softwaredesign tool 234.

Process 100 may further include obtaining one or more aerial photographsof the structure (depicted by numeral 112). For example only, a designtechnician may obtain one or more aerial photographs of the structure(e.g. a house). By way of example only, one or more aerial photographsmay be obtained via an online repository of to-scale aerial photographs.As a more specific example, aerial photographs may be obtained via“Pictometry Online,” which is an online repository of to-scale aerialphotographs and includes advanced measurement tools that are useful forobtaining highly accurate azimuth and distance calculations. “PictomertyOnline” is developed by Pictometry International Corp. of Rochester,N.Y. Based on the one or more aerial photographs, azimuth may becalculated. As will be understood by a person having ordinary skill inthe art, azimuth is an angular measurement of the direction a roof isslanting in degrees clockwise from North (e.g., if the roof slants tothe South, the Azimuth would be 180°, and a roof slanting to the Eastwould have an Azimuth of 90°). Furthermore, the photographs may bescaled into a CAD file. FIGS. 7 and 8 respectively include screenshots236 and 238, each of which include an example aerial photo obtained viaan online repository.

Process 100 can also include generating, via roof measurements and tiltinformation from the site survey, an illustration of each roof sectionin order of approximated production efficiency (e.g., most south-facing,east-facing, west-facing, then north-facing factoring in possibleshading) in a detailed, to-scale, roof plan (depicted by numeral 114).For example only, a design technician may generate an illustration ofeach roof section in order of approximated production efficiency. Theroof plan may be generated (e.g., drawn) based on the site surveymeasurements. The actual measurements on the roof illustration(s) in thesite survey form may be followed as closely as possible. Theseillustrations may provide the most accurate, to-scale representation ofthe actual placement of the modules on the roof of the structure. FIG. 9is a screenshot 240 depicting example roof plans.

Process 100 may also include applying required offsets to eachillustrated roof section (depicted by numeral 116). For example only, adesign technician may apply required offsets to each illustrated roofsection. Roof offset requirements may include a standard offsetrequirement (e.g., minimum offset of fifteen inches from every ridge andeight inches from all other sides), jurisdictional requirements, orboth. Jurisdictional requirements may include, for example, the“California Fire Code” requirement (i.e., currently—minimum three footwide offset from ridge to top edge of an array, minimum three foot wideoffset between an edge of an array and a load bearing wall, and aminimum eighteen inch offset between an edge or corner of an array andany hip or valley where modules are located on both sides of the hip orvalley. If modules are only on one side, no offset is required).Further, another jurisdictional requirement may include a “Simi Valley”requirement (i.e., currently—minimum four foot offset from any edgerunning perpendicular to an eve). In addition, other offset requirementsfor Hawaii (i.e., currently—one foot offset from all plumbing vents),New York (i.e., currently—eighteen inch offset from one side of a ridgeand eighteen inch offset from one side running perpendicular to theeve), and Ontario (i.e., currently—three foot offset from all foursides) may exist. FIG. 10 is a screenshot 245 including example roofplans including required offsets.

Process 100 may further include providing a sufficient number of moduleson an illustration (e.g., drawing) to either fill all surveyed roofsections, meet the number of modules estimated (i.e., by the pre-designtechnician), or both (depicted by numeral 118). For example only, adesign technician may provide a sufficient number of modules on anillustration. FIG. 11 is a screenshot 250 including example roof plansincluding a plurality of modules 252 to fill all surveyed roof sectionsand/or meet the number of modules estimated.

In addition, process 100 includes adjusting previously taken photographs(i.e., photographs of the sky at different locations on the roof)(depicted by numeral 120). For example only, a design technician mayadjust the previously taken photographs (e.g., Solmetric SunEyephotographs). FIG. 12 is a screenshot 255 including a sky photograph.

In addition, process 100 may include recreating roof sections via anapplication tool (e.g., a software program) (depicted by numeral 122).As an example, a design technician may recreate the roof sections. Byway of example only, roof sections may be recreated via Solmetric's PVDesigner software, which may be used (e.g., by a design technician) tocalculate estimated production of modules in any given area. The PVDesigner software has tools for drawing a roof section, placing modules,and placing SunEye picture locations. The software may uselocation-specific weather information to calculate estimated solaraccess and production for each module, roof section, and for an entiresolar array. Further, the software calculates estimated productionlevels for each module, roof section, and for the entire photovoltaicsystem. FIG. 13 includes a screenshot 260 including a roof plangenerated via an application tool.

Process 100 may further include calculating a number of estimated “sunhours” for each roof section and comparing the estimation againstrequired production levels (depicted by numeral 124). The term “sunhours” represents the number of hours of exposure a module or an arrayof modules will have to the sun annually. The number of sun hours may becalculated by dividing the estimated system production by the systemsize. Sun hour requirements may vary depending on a geographic location.For example, in California, 1300 sun hours per year is considered low,and 1150 sun hours or less per year may result in an automaticsubscription cancellation. Further, in Maryland, 1100 sun hours per yearis considered low, and 1000 sun hours or less per year may result in anautomatic subscription cancellation. In addition, for New York,Massachusetts, Hawaii, and New Jersey, 1000 sun hours per year isconsidered low, and 950 sun hours or less per year may result in anautomatic subscription cancellation. It is noted that a system (i.e., anaccount) may be approved or rejected based on a sun hour estimation. Byway of example only, if a roof section's calculated sun hours fallsbetween the automatic cancellation and low sun hours specifications, butthe system's sun hours are above the low sun hour minimum, then furtherconsideration (e.g., further calculations) may be taken into account todetermine if approval is necessary. Further, if all individual roofsections are within 95% of the low sun hour minimum, the system may beapproved. If any of the individual roof sections fall under 95% of thelow sun hour minimum, further consideration may be necessary (e.g., by adepartment head) for approval of the system.

Process 100 includes fine-tuning the number of modules to match, asclosely as possible, an ideal offset previously specified (depicted bynumeral 126). As an example, a design technician may fine-tune thenumber of modules. FIG. 14 includes a screenshot 270 illustrating anexample roof plan including a fine-tuned number of modules.

Further, process 100 includes adding trunk cable and hatching to a roofplan to indicate separate circuits (depicted by reference numeral 128).As an example, a design technician may add trunk cable and hatching.According to one embodiment, up to seventeen modules can be placed oneach circuit. A one-circuit system may connect to the junction boxes,then directly to a main bus bar solar breaker. A multi-circuit systemmay have all circuits connected to the junction boxes, then toindividual breakers in a combiner panel, which then connects to a mainbus bar solar breaker. In one specific embodiment, some module circuitsmay be coupled to a 15A breaker, and some other module circuits may becoupled to a 20A breaker. Further, up to eight modules may be coupled toa 10A breaker, if required.

For trunk cable addition, “splines” may be placed on the roof plan(e.g., by the design technician) to represent a trunk cable connectingDC-AC inverters, in circuits, to the junction boxes (e.g., up to tenlandscape-oriented modules may be on the same spline and up to thirteenportrait-oriented modules may be on the same spline). Splines mayoriginate at a junction box and end at a module, as an example. Further,for example, splines may traverse across modules, then down. FIG. 15includes a screenshot 280 depicting a roof plan including a number ofmodules, trunk cable, and hatching.

Process 100 may also include adding one or more conduits to a roof plan(depicted by numeral 130). As an example, a design technician may addone or more conduits to a roof plan. A conduit may be shown on both thesite plan and the roof plan to represent the actual conduit on the roofthat will contain the electrical wiring between junction boxes and theelectrical panel or combiner panel. It is noted that conduit should bekept to a minimum length possible to avoid power loss due to a voltagedrop. Further, a conduit visible from the street is to be avoidedwherever possible, and conduit may run as close to the ridge aspossible. FIG. 16 is a screenshot 290 illustrating roof plans includinga number of modules, trunk cable, hatching, and a conduit.

Process 100 may also include determining one or more constraints for thephotovoltaic system (depicted by numeral 132). For example, a designtechnician may determine one or more constraints. A “customer usage”constraint is reached when the estimated production of the system hasreached the desired offset percentage. With this constraint, thecustomer is receiving the ideal savings according to their usage. A “maxkW” constraint is reached when the system size reaches alocally-enforced photovoltaic system size limit. A “roof space”constraint is reached when there is no further space to place modules onany of the roof sections surveyed. An “electrical” constraint is reachedwhen the number of modules is limited by the electrical capacity of thestructure. A system may be designed and can be installed with theelectrical constraint, but if the customer chooses to upgrade his/herelectrical system, the system may be redesigned, after a new sitesurvey, to reflect the new electrical requirements. A “solar access”constraint is reached when the placement of more modules is limited bythe estimated production in an area of the roof. The solar accessconstraint can sometimes be remedied by the removal of trees or otherobstructions. In such cases, a new site survey may be required before aredesign will be considered.

Process 100 may further include generating, and possibly printing,shading reports (e.g., Solmetric shading reports) and productionestimates (depicted by numeral 134). According to one example, a designtechnician may generate, and possibly print shading reports andproduction estimates. FIG. 17 includes a screenshot 300 depicting anexample shading report and an example production estimate.

In addition, process 100 may include determining point-loads, mountingfoot placement, and bill of materials via the design tool that allowsfor configuring a system according to site-specific parameters (depictedby numeral 136). For example, a design technician may determinepoint-loads, mounting foot placement, and bill of materials. Athird-party tool may aid in array layouts, determine span and cantileverallowances, and generate bills of materials and more. Further, thethird-party tool may generate two reports that are saved to the customerdesign folder: an engineering report with point-load information, and abill of materials. By way of example only, an online tool “Zepulator”developed by ZepSolar of San Rafael, Calif. may be used as thethird-party tool. In addition, the estimated production report numbersmay be validated by, for example only, a CAD Technician. Morespecifically, a determination may be made as to whether 1) a DC-ACderate factor is substantially 85%; and 2) a number and type of moduleson the report matches the number and type of modules on the roof plan.Further, additional correction may be made (e.g., by a designtechnician), if necessary. As will be appreciated by a person havingordinary skill in the art, a series of losses, combined together, deratean array's performance. These factors (i.e., derate factors), whichinclude voltage drop, shading, and DC-AC conversion loss, among others,may be used to estimate real-world production of the photovoltaicsystem. FIG. 18 is a screenshot 310 illustrating an example third-partytool.

Moreover, process 100 includes creating a site plan of the home,including estimated property lines and required roof offsets, via one ormore photographs (e.g., Pictometry photograph) (depicted by numeral138). As an example, a CAD technician may create a site plan. The siteplan may be drawn based on one or more aerial photographs (e.g.,Pictometry aerial photograph). It is noted that the drawing may not beto scale and may include the structure, complete photovoltaic array, andapproximated property line. FIG. 19 is a screenshot 320 depicting anexample photograph 322 that may be used to generate a site plan.

Process 100 may also include adding modules to the site plan as designed(depicted by numeral 140). As an example, a CAD technician may addmodules to the site plan. FIG. 20 is a screenshot 330 including a siteplan 332 including a plurality of modules. Process 100 may also includegenerating (e.g., drawing) a conduit on the site plan to provide aprotected pathway for electrical wiring (depicted by numeral 142). Byway of example, a CAD technician may generate a site plan including aconduit. FIG. 21 is a screenshot 340 including a conduit and a pluralityof modules on a site plan 342. Further, process 100 may includecompleting drawing properties with system information (depicted bynumeral 144). As an example, a CAD Technician may complete CAD drawingproperties with system information. FIG. 22 is a screenshot 350including a site plan and drawing properties window 352. Moreover,additional notes may be added to and/or associated with the site planand the roof plan (depicted by numeral 146). FIG. 23 is a screenshot 360including notes 362 on a site plan. FIG. 24 is a screenshot 370illustrating notes on a roof plan.

Process 100 may also include selecting a correct electrical one-linediagram (depicted by numeral 148) (e.g., specified by the Pre-DesignTechnician). As an example, a CAD Technician may select the correctelectrical one-line diagram.

Further, process 100 may include publishing CAD drawings to thecustomer's design folder (depicted by numeral 150). As an example, a CADtechnician may publish CAD drawings to the design folder. The CADdrawings may include, but are not limited to, the site plan, the roofplan, mounting details, and an electrical one-line diagram for alldesigns. CAD drawings may also include a connection layout, a mountingfoot spacing diagram, roof detail, module height detail, and placard.FIG. 25 is a screenshot 380 depicting a one-line diagram in a CAD tool,and FIGS. 26 and 27 respectively include screenshots 390 and 395, eachillustrating CAD drawings being published.

Process 100 may also include completing a NREL PVWatts process (depictedby numeral 152). As an example, a CAD technician may complete the NRELPVWatts process. NREL PVWatts is an online tool provided by the NationalRenewable Energy Laboratory (NREL) of the U.S. Department of Energy. ThePVWatts tool includes an interactive map-based interface to rapidlyutilize a PVWatts calculator, which is a basic solar modeling tool thatcalculates hourly or monthly photovoltaic energy production based onminimal inputs. Currently, a NREL PVWatts process may only be requiredin certain geographic locations (e.g., New Jersey and Maryland).Currently, New Jersey requires an “ideal” estimate and an “actual”estimate, while Maryland requires only an “actual” estimate. An idealestimate is calculated for each roof section array based off of thearray's actual system size and using PVWatts' pre-defined “ideal”conditions. An actual estimate is calculated for each roof section arraybased off of the array's actual system size, tilt, and azimuth,factoring in an estimated DC-AC derate factor calculated with the designtool.

Additionally, process 100 can include populating the design tool withsystem information (depicted by numeral 154). The design tool may bepopulated by, for example, a CAD technician. FIG. 28 is a screenshot 400depicting the design tool. FIG. 29 is another screenshot 410 depictingthe design tool.

Process 100 may also include generating engineering and data pages fromthe design tool (e.g., printing as PDF files) (depicted by numeral 156).The engineering and data pages may be generated by a CAD technician, forexample. Data pages may contain calculated data for derate factors,electrical and point-load information, and installation materials andcosts estimates.

Process 100 may further include merging engineering documents from thedesign tool and the engineering files (e.g., engineering files developvia Zepulator) into an engineering packet to save in the customer designfolder (depicted by numeral 158). A CAD technician, for example, maymerge the engineering document and the engineering files into anengineering packet. FIG. 30 is a screenshot 420 depicting engineeringdocuments being merged into an engineering packet.

Furthermore, process 100 may include merging the published CAD, the billof materials, and the data document from the design tool into aninstaller packet, which may be saved in the customer design folder(depicted by numeral 160). For example, a CAD technician may merge thepublished CAD, the bill of materials, and the data document from thedesign tool into an installer packet. FIG. 31 is a screenshot 430illustrating various documents being merged into an installer packet.

In addition, process 100 may include creating an approximate look forthe modules on the structure in an image (depicted by reference numeral162). It is noted that act 162 may require a photograph of sufficientquality. Further, as an example, a software application (e.g., AdobePhotoshop Elements) may be used (e.g., by a CAD technician) to create animage illustrating the approximate look for the modules on thestructure. This may be created to give the customer an idea of what themodules will look like on the structure (e.g., their house). The “frontof the house” photograph (e.g., taken by a site surveyor) is typicallyused, unless there is a more appropriate photograph. In this example,the CAD technician, for example, simply places modules as they would bevisible on the photograph, according to the site plan and roof plan.FIG. 32 is a screenshot 440 including an image with a module on astructure.

Process 100 may also include compiling the customer packet and saving itto the customer's design folder (depicted by reference numeral 164). ACAD technician, for example, may compile and save the customer packet.The customer packet may be sent to the customer to show them theproposed design for their photovoltaic system. This packet may include acover page, a welcome letter to the customer and their family, aPhotoshop image of the customer's home (if available), each of the pagesin the published CAD, and/or the estimated production report. FIG. 33 isa screenshot 450 including various documents of a customer packet.

Process 100 can further include uploading all relevant files from thecustomer's design folder into a management system (depicted by act 166).For example, a CAD technician may upload the relevant files. Amanagement system may be configured as a solution for storing andtracking customer personal and account-specific information. Filesuploaded to the management system may include published CAD drawings, aplacard (where required), an installer packet, an engineering packet, anestimated production report, a customer packet, a site survey form,and/or site survey photographs. Other files may be uploaded as required.FIG. 34 includes a screenshot 460 depicting a customer design folder,FIG. 35 includes a screenshot 470 illustrating a management system, andFIG. 36 includes a screenshot 480 depicting files from a customer designfolder.

Process 100 may also include populating the management system withsystem information (depicted by act 168). The management system may bepopulated by, for example, a CAD technician. FIGS. 37 and 38respectively include screenshots 490 and 500, each depicting themanagement system.

In addition, process 100 may include verifying accuracy of all files(depicted by act 170). As an example, a post-install technician mayverify the accuracy of files. Any noted error may be handled byappropriate personnel. For example, a design technician may handledesign errors and a CAD technician may handle CAD errors. Errors may becorrected and re-submitted to, for example, a post-install technician.

Further, process 100 can include sending a customer packet to a customerfor review and approval (depicted by act 172). If not approved, arepresentative may work with the customer for redesign. If approved, apermitting process may be initiated.

Process 100 may further include completing a structural review (depictedby act 174). By way of example, a structural engineer may review theroof's structural integrity for photovoltaic installation.

Process 100 may also include installing the photovoltaic system(depicted by act 176) and checking actual installation photographs(i.e., photographs taken by installers at the time of installation) andinstallation work order against original, published CAD files (depictedby act 178). Process 100 may also include adjusting a report and CADfiles to reflect actual installation (depicted by act 180). For example,a post-install technician may adjust the report and CAD files.

Further, system information of the management system may be updated andthe as-built files (e.g., site plan, roof plan, mounting details,electrical one-line diagram for all designs) may be uploaded (depictedby act 182). As an example, a post-install technician may update thesystem information and update the as-built files.

In addition, process 100 may include performing a post-installationstructural review (depicted by act 184). The review may be used toverify that the installation followed the structural reviewrequirements.

FIG. 39 is a flowchart of a method 600, according to an embodiment ofthe present invention. Method 600 includes determining a method ofinterconnection to couple a photovoltaic system to an electrical systemof a structure (act 602). Method 600 further includes determining, viaan electronic device, an ideal usage offset ratio for the photovoltaicsystem based on a known utility rate associated with the structure (act604). In addition, method 600 includes estimating a number of modulesrequired to meet the determined ideal usage offset ratio (act 606).Moreover, method 600 includes generating, via the electronic device,installation information with the design tool including requiredinstallation materials, estimated costs, point-load, and electricalinformation for photovoltaic system (act 608).

Although the foregoing description contains many specifics, these shouldnot be construed as limiting the scope of the invention or of any of theappended claims, but merely as providing information pertinent to somespecific embodiments that may fall within the scopes of the inventionand the appended claims. Features from different embodiments may beemployed in combination. In addition, other embodiments of the inventionmay also be devised which lie within the scopes of the invention and theappended claims. The scope of the invention is, therefore, indicated andlimited only by the appended claims and their legal equivalents. Alladditions, deletions and modifications to the invention, as disclosedherein, that fall within the meaning and scopes of the claims are to beembraced by the claims.

What is claimed:
 1. A method, comprising: performing a site survey at alocation including a structure to generate site survey informationincluding customer information, electrical information for thestructure, illustrations of a roof of the structure, measurements of theroof, roof obstruction information, tilt information for the roof,photos of the structure, photos of the sky from one or locations on theroof, a utility bill for the structure, and structure utility usageinformation; determining a method of interconnection to couple aphotovoltaic system to an electrical system of the structure based on atleast one photo from the site survey information; determining, via anelectronic device, an ideal usage offset ratio for the photovoltaicsystem based on at least some of the site survey information;estimating, via the electronic device, a number of modules required tomeet the determined ideal usage offset ratio; generating a roof planbased on at least a portion of the site survey information, the roofplan including an illustration of each roof section of the roof, eachroof section illustration depicting one or more modules of the number ofmodules and at least one of a trunk cable, hatching, and a conduit;comparing estimated production levels for the photovoltaic systemincluding the number of modules at the location to required productionlevels; one of approving and rejecting the photovoltaic system based onthe comparison of the estimated production levels and the requiredproduction levels; generating, via the electronic device, installationinformation including the determined method of interconnection, theideal usage offset ratio, the number of modules required to meet thedetermined ideal usage offset ratio, the roof plan, requiredinstallation materials, estimated costs, point-load, an estimatedproduction report, and electrical information for the photovoltaicsystem; and providing the installation information to a customer forapproval.
 2. The method of claim 1, further comprising providing anapplication program of the electronic device with information related tothe photovoltaic system including the estimated number of modules. 3.The method of claim 2, wherein providing an application program withinformation comprises providing at least one of customer accountinformation, location-specific information, and electrical codes to theapplication program.
 4. The method of claim 2, wherein determining anideal usage offset ratio for the photovoltaic system comprisesdetermining the ideal usage offset ratio for the photovoltaic systemwith the application program.
 5. The method of claim 2, whereinestimating a number of modules comprises estimating a number of moduleswith the application program.
 6. The method of claim 1, whereingenerating installation information comprises generating a data documentincluding information related to the required installation materials andestimated costs and an engineering document including point-loadinformation and electrical information.
 7. The method of claim 1,wherein determining an ideal usage offset ratio comprises determiningthe ideal usage offset ratio for the photovoltaic system based on aknown utility rate and one or more utility discounts associated with thestructure.
 8. The method of claim 1, wherein performing the site surveyfurther comprises generating the site survey information including atticinformation for the structure.
 9. The method of claim 1, furthercomprising: obtaining an aerial photo of the structure; calculating anazimuth of a roof of the structure from the aerial photo; and scalingthe aerial photo into a computer-aided design (CAD) file.
 10. The methodof claim 9, wherein generating a roof plan comprises illustrating one ormore roof sections on the CAD file in order of approximated productionefficiency in the roof plan based on roof measurements and tiltinformation.
 11. The method of claim 10, further comprising applyingrequired offsets to each roof section illustration of the CAD file. 12.The method of claim 10, further comprising adding at least one module tothe CAD file to at least one of fill each roof section and meet thenumber of modules required for the determined ideal usage offset ratio.13. The method of claim 10, further comprising calculating estimatedproduction levels for each module, each roof section, and thephotovoltaic system.
 14. The method of claim 10, further comprising:calculating sun hours for each roof section; and comparing thecalculated sun hours with required sun hour levels.
 15. The method ofclaim 10, further comprising adding trunk cable, hatching, and conduitto each roof section of the CAD file.
 16. The method of claim 1, furthercomprising determining one or more constraints for the photovoltaicsystem.
 17. The method of claim 1, further comprising determiningpoint-loads, mounting foot placement, and bill of materials for thephotovoltaic system.
 18. The method of claim 1, further comprisingcreating a site plan of the structure including estimated property linesand required roof offsets based on an aerial photo.
 19. The method ofclaim 18, further comprising adding the estimated number of modules anda conduit to the site plan.
 20. The method of claim 1, furthercomprising installing the photovoltaic system.
 21. A system, comprising:an electronic device including a processor; a computer-readable mediumcoupled to the processor; and an application program stored in thecomputer-readable medium, wherein the application program, when executedby the processor, is configured to: receive site survey information froma site survey performed at location including a structure, the sitesurvey information including customer information, electricalinformation for the structure, illustrations of a roof of the structure,measurements of the roof, roof obstruction information, tilt informationfor the roof, photos of the structure, photos of the sky from one orlocations on the roof, a utility bill for the structure, and structureutility usage information; determine an ideal usage offset ratio for aphotovoltaic system based on one or more parameters associated with thestructure determined via at least some of the site survey information;estimate a number of modules required to meet the determined ideal usageoffset ratio; generate a roof plan based on at least a portion of thesite survey information, the roof plan including an illustration of eachroof section of the roof, each roof section illustration depicting oneor more modules of the number of modules and at least one of a trunkcable, hatching, and a conduit; compare estimated production levels forthe photovoltaic system including the number of modules at the locationto required production levels; one of approve and reject thephotovoltaic system based on the comparison of the estimated productionlevels and the required production levels; and generate installationinformation for the photovoltaic system based at least partially onlocation-specific information and the estimated number of modules. 22.The system of claim 21, wherein the installation information comprisesinformation related to required installation parts, estimated costs,point-load, and electrical requirements for the photovoltaic system. 23.The system of claim 21, wherein the application program is furtherconfigured to receive at least one of customer account information,location-specific information, and electrical codes.
 24. Anon-transitory computer-readable storage medium storing instructionsthat when executed by a processor cause the processor to performinstructions, the instructions comprising: receiving site surveyinformation from a site survey performed at location including astructure, the site survey information including customer information,electrical information for the structure, illustrations of a roof of thestructure, measurements of the roof, roof obstruction information, tiltinformation for the roof, photos of the structure, photos of the skyfrom one or locations on the roof, a utility bill for the structure, andstructure utility usage information; determining an ideal usage offsetratio for a photovoltaic system based on one or more parametersassociated with the structure determined via at least some of the sitesurvey information; estimating a number of modules required to meet thedetermined ideal usage offset ratio; generating a roof plan based on atleast a portion of the site survey information, the roof plan includingan illustration of each roof section of the roof, each roof sectionillustration depicting one or more modules of the number of modules andat least one of a trunk cable, hatching, and a conduit; comparingestimated production levels for the photovoltaic system including thenumber of modules at the location to required production levels; one ofapproving and rejecting the photovoltaic system based on the comparisonof the estimated production levels and the required production levels;and generating installation information for the photovoltaic systembased at least partially on location-specific information and theestimated number of modules.
 25. The non-transitory computer-readablestorage medium of claim 24, wherein generating installation informationcomprises generating installation information comprising requiredinstallation materials, estimated costs, point-load, and electricalinformation for the photovoltaic system.